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Alberta's oil sands contain vast bitumen resources with reserves that are the second
largest in the world, after Saudi Arabia. According to the Alberta Energy and Utilities
Board (EUB), remaining established reserves are estimated to be 28 billion cubic metres (174 billion barrels) at year-end 2004.

Why did the NEB prepare this Energy Market Assessment (EMA)?

In May 2004, the Board released an Energy Market Assessment (EMA) entitled Canada's Oil Sands: Opportunities and Challenges to 2015.
It contained an objective assessment on the major aspects of the oil sands industry
and assessed the opportunities and challenges facing the development of the resource.
Since then, the conditions surrounding oil sands development have changed significantly.
As a result, the Board decided to provide an update.

What is the Board's outlook for oil sands development?

It is expected that rapid development of Canada's oil sands will continue. There
are, however, issues and uncertainties associated with the development of this resource.
The rate of development will depend on the balance that is reached between the opposing
forces that affect the oil sands. High oil prices, international recognition, stable
investment climate, global growth in oil demand, size of the resource base and proximity
to the large U.S. market, and potentially access to other markets, encourage development.
On the other hand, water use, air emissions, local infrastructure and services, labour
requirements, natural gas costs and the light/heavy oil price differential are concerns
that could potentially inhibit the development of the resource.

What are the Board's main conclusions?

In 2005, oil sands production surpassed 175 000 cubic metres
(1.1 million barrels) per day. By 2015, production is expected
to almost triple to about 472 000 cubic metres (3.0 million barrels) per day.

Higher oil prices have boosted revenues; however, operating costs have also increased
significantly with the rise in energy prices. Capital costs have risen dramatically
due to higher prices for steel, cement and equipment.

In the short-term, expansions in traditional oil markets will occur and, in the
longer term, additional market expansion or new markets will be required.

Pipeline capacity out of western Canada could be near full utilization in 2007
and, therefore, additional pipeline capacity will be required.

Currently, there is a limited supply of skilled tradespersons and this tight
labour market is expected to continue in the near future.

Oil sands mining operations use a significant volume of water and the limited available supply from the Athabasca River could be a constraint on future expansion plans.

Regions associated with oil sands development enjoy several economic benefits
but at costs to the social well-being of the communities, including a shortage of
available housing and stress on public infrastructure and services.

Natural gas requirements for the oil sands industry are projected to increase
substantially from 0.7 billion cubic feet per day in 2005 to
2.1 billion cubic feet per day in 2015. High natural gas
prices have encouraged oil sands operators use gas more efficiently and to look for
alternative fuels.

How much money is being invested in the oil sands?

Over C$125 billion in oil sands recovery projects have been proposed during the
2006 to 2015 period; however, all projects are not expected to proceed. The NEB's
Base Case projection assumes capital expenditures of C$94 billion over this period.

What are the key assumptions used in this analysis in comparison to the May 2004 report?

A comparison of key assumptions between this analysis (2005 dollars) and the
2004 report (2003 dollars) is provided below:

Assumptions

June 2006 Report

May 2004 Report

WTI crude oil price

US$50 per barrel

US$24 per barrel

NYMEX natural gas price

US$7.50 per MMBtu

US$4.00 per MMBtu

Light/Heavy price differential

US$15 per barrel

US$7 per barrel

Canadian dollar exchange rate

US$0.85

US$0.75

What are the operating costs and the supply costs of producing a barrel of oil from the oil sands?

The estimated operating costs range from $6 to $14 per barrel for bitumen
and $18 to $22 per barrel for synthetic crude oil. The estimated supply
costs ranges from $14 to $24 per barrel for bitumen and from $36 to $40
per barrel for synthetic crude oil. Supply costs include operating costs, capital
costs, taxes, royalties and the rate of return on investment.

At what oil price range are oil sands operations economic?

Integrated mining and SAGD (Steam Assisted Gravity Drainage) operations are estimated
to be economic at US$30 to $35 per barrel WTI. However, continued escalation
in material and labour costs pose a risk to this outlook. Furthermore, higher natural
gas prices and blending costs would also increase this estimate. On the other hand,
advancement in recovery and upgrading technologies hold potential to improve economics.

What is the NEB's projection for western Canadian oil supply, including oil by 2015?

Total oil supply from western Canada is expected to grow from 365 000 cubic metres (2.4 million barrels) per day in 2005 to 613 000 cubic metres (3.9 million barrels) per day in 2015, an increase of 68 percent. In 2005, oil sands production surpassed 175 000 cubic metres (1.1 million barrels) per day, and it is expected to almost triple to about 472 000 cubic metres (3.0 million barrels) per day by 2015.

What is the natural gas requirement relative to oil sands production?

It takes about 34 cubic metres (1 200 cubic feet) of natural
gas to produce one barrel of bitumen from in situ projects and about 20 cubic metres (700 cubic feet) for integrated projects. Currently, the oil sands industry
uses about 21 million cubic metres (0.7 billion cubic feet)
per day of purchased gas, or about five percent of the Western Canada Sedimentary
Basin production. By 2015, this increases to about 60 million cubic metres
(2.1 billion cubic feet) per day, or nearly 12 percent, assuming
gas production remains at 482 million cubic metres (17 billion cubic feet)
per day.

Will there be markets to take the rising volumes of oil sands production?

Based on industry consultations and the Board's internal analysis market expansion
for growing oil sands production could unfold in the following way:

Step One: Fill up existing markets, including Washington State, PADD II and
PADD IV and some additional volumes in Canada.

Step Three: Branch out and develop new markets. In this connection, a new pipeline
or a major pipeline expansion to the west coast would be required to deliver crude
oil to California and the Far East.

The following map illustrates the major oil pipelines in Canada and the United
States as well as the North American markets.

Will there be pipeline capacity to transport the additional oil sands production?

Pipeline capacity out of western Canada could be near full utilization starting
in 2007. The industry needs to decide which markets hold the greatest potential and
move forward on pipeline expansions or new pipelines.

How much water is required to produce one cubic metre of oil from the oil sands?

The water requirement ranges from 2 to 4.5 cubic metres of
water to produce one cubic metre of synthetic crude oil in a mining operation.
Mining operations use surface water and recycled water.

In SAGD operations, although 90 to 95 percent of the water used for steam
to recover bitumen is reused, every cubic metre of bitumen produced still requires
about 0.2 cubic metres of additional groundwater. Some surface water is
used but most operations use fresh and saline groundwater.

What are the major issues surrounding water usage by oil sands operations?

Stakeholders agree that oil sands operations must improve their water usage. At
current rates of withdrawal from the Athabasca River, there would be insufficient
volumes to support all the announced oil sands mining projects. River flows are low
in the winter and the removal of large volumes of water during these periods is a concern.

Waste water that is collected from the extraction process is contained in large
tailings ponds. There is a debate on whether the tailings ponds can be reclaimed to
become biologically productive ecosystems.

How much progress has the industry made to reduce emissions?

Although significant progress has been made towards decreasing the intensity of
Greenhouse Gas (GHG) emissions produced by oil sands operators, the increased production
of oil counterbalances these gains and total emissions are expected to rise.

Given the current high oil prices there is renewed interest in carbon dioxide (CO2)
capture and storage for enhanced oil recovery (EOR) to increase production from mature
Canadian oil reserves. A major barrier to this development would be the need for a
dedicated CO2 pipeline to transport CO2 from the oil sands projects to
the light oil pools in central Alberta. The policy regarding long-term storage is
also uncertain.

Is there sufficient skilled labour to meet the pace of development?

It is uncertain if the industry is able to increase the supply of skilled workers.
A limited supply has the potential to restrict the pace of development.

Are there infrastructure concerns?

The Wood Buffalo region, the area of most intensive development, has experienced
deficiencies in community service delivery and infrastructure development.

What impact has higher natural gas prices had on cogeneration in the oil sands?

Higher natural gas prices have been one of the factors supporting a trend for oil
sands producers to build cogeneration to meet their own electricity demand. There
has been little incentive to install excess capacity for sale to the grid.

How can the oil sands industry provide opportunities for the petrochemical sector?

The bitumen upgrading process produces off-gas from which ethane and other light
hydrocarbons could be extracted and used by the petrochemical industry. Currently,
ethane and most of the other light hydrocarbons remain in the off-gas and are used
as fuel for operations.